Well location and well trajectory determination method, drilling speed increase method, modification and production increase method, and device and medium

Abstract

A well location and well trajectory determination method, comprising: on the basis of a stratum pressure test, and a flow phase constraint of each stratum, establishing a full-stratum-series three-dimensional rock mechanical parameter field model, so as to obtain full-stratum-series rock mechanical parameters; on the basis of a geological structure, and a stratum pressure field of each stratum, establishing a three-dimensional full-stratum-series stress field prediction model, so as to acquire full-stratum-series three-dimensional stress field parameters; on the basis of the full-stratum-series rock mechanical parameters, the full-stratum-series three-dimensional stress field parameters and a three-dimensional natural fracture model, establishing a natural fracture activity prediction model, so as to evaluate fracture activity; and determining a well location and a well trajectory on the basis of a three-dimensional original field geostress model, a three-dimensional fracturability prediction model, the fracture activity and a three-dimensional collapse pressure prediction model. By means of the method, the effects of drilling speed increases and modification and production increases can be achieved in complex oil and gas field blocks. Further provided are a drilling speed increase method, a modification and production increase method, a well location and well trajectory determination apparatus, an electronic device, and a computer-readable storage medium.

Description

Well location and trajectory determination, drilling speed-up and production increase methods, equipment and media Technical Field

[0001] The present invention relates to the technical field of deep-earth oil and gas resource exploration and development, and in particular to a method for determining well locations and well trajectories, a method for increasing drilling speed, a method for increasing production through transformation, an electronic device, and a computer-readable storage medium. Background Art

[0002] Geomechanical parameters are a key factor influencing oilfield drilling and completion engineering, as well as reservoir engineering, including oil and gas exploration results, reservoir stimulation, and fracturing. They play a crucial role in petroleum engineering. In actual oil and gas field production, geomechanical parameters play a crucial role throughout the entire lifecycle of reservoir exploration and development. Building on geological understanding and engineering practice, and integrating regional and wellbore geology, logging, geophysical exploration, drilling, testing, and fracturing data to establish a geomechanical parameter model tailored to oil and gas field production needs, and using this geomechanical parameter model to evaluate the geomechanical characteristics of oil and gas fields, and applying these characteristics to the entire lifecycle of reservoir exploration and development, including trap prediction, well placement, drilling engineering, tracking while drilling, completion and stimulation, development planning, and gas storage construction, will help address issues related to reservoir quality evaluation, well location and trajectory optimization, safe and rapid drilling, and efficient completion and production improvement, generating significant economic benefits.

[0003] However, most current research on geomechanical parameters focuses on determining the mechanical properties of geological materials and their relationship to geological structure and stress states, thereby studying and analyzing the structural characteristics and distribution patterns of structural units at all levels to guide oil and gas exploration and development. However, these methods have yet to address specific production issues in oil and gas exploration and development. For example, existing geomechanical characteristic evaluation methods in oil and gas exploration and development generally focus on rock mechanics experiments on deep rock samples, constructing parameter calculation models based on these experiments, and using well logging data to quantitatively evaluate the one-dimensional rock mechanics parameters of the wellbore. This evaluation process can only invert the mechanical characteristics of the rock at a local scale, but cannot invert the comprehensive mechanical properties from the perspective of oil and gas reservoirs and specific formations. It also cannot invert the effects of faults and natural fractures on rock mechanics. Furthermore, it is difficult to analyze the geomechanical characteristics of oil and gas fields at a three-dimensional scale, and cannot effectively address the engineering geology challenges facing oil and gas exploration and development.

[0004] In addition, although some scholars have tried to evaluate the geological parameters of oil and gas fields and apply the geomechanical characteristics obtained from the evaluation to drilling speed-up and completion transformation to increase production, they mainly focus on the application of certain technologies and have not achieved good results in speed-up and production increase. For example, in drilling speed-up, the existing technology mainly considers the influence of geomechanical characteristics in the process of predicting the pore pressure of the formation, and does not fully consider that the geomechanical characteristics will also have a certain impact on the prediction of the wellbore stability of various different rock types. Therefore, when applying geomechanical characteristics in drilling speed-up, serious wellbore instability usually occurs, affecting the speed-up effect. In completion transformation to increase production, the existing technology only determines the geomechanical characteristics through the physical parameters of the wellbore rock and optimizes the completion transformation process. It does not fully consider the influence of the distribution of natural fractures and the distribution of the reservoir around the well on the geomechanical characteristics, resulting in unsatisfactory transformation and production increase results.

[0005] In summary, from a comprehensive perspective, traditional technologies for increasing the speed and production of oil and gas fields consider relatively simple factors. In most cases, they consider geological research, geophysics, and other aspects, without fully considering the impact of geostress, rock mechanics, and fracture mechanics on drilling speed and completion production, resulting in the speed-up and production increase effect not meeting expectations. In addition, the prerequisite for increasing drilling speed and production is the accurate selection of well locations and the reasonable design of well trajectories. Traditional technologies have not formed an integrated solution approach, considering it from the source, and treating well trajectory optimization, drilling speed-up, and completion production increase as a complete production process. At each node in this production process, oil and gas field geomechanics research is applied one by one to achieve a significant increase in production through transformation, thereby achieving the ultimate goal of efficient development of complex oil and gas reservoirs.

[0006] Summary of the Invention

[0007] The purpose of the embodiments of the present invention is to provide a method for determining well locations and well trajectories, a method for increasing drilling speed and completing wells to increase production, at least to solve the technical problem that the existing technology has not yet integrated the research on oil and gas field geomechanics into production processes such as well trajectory optimization, increasing drilling speed and increasing completion production, and thus cannot achieve efficient development of complex oil and gas reservoirs.

[0008] In order to achieve the above-mentioned objectives, the present invention provides a method for determining well locations and well trajectories, which comprises the following steps: establishing a three-dimensional rock mechanics parameter field model for the entire formation based on formation pressure testing and flow phase constraints of each formation to obtain rock mechanics parameters for the entire formation; establishing a three-dimensional stress field prediction model for the entire formation based on geological structures and formation pressure fields of each formation to obtain three-dimensional stress field parameters for the entire formation; establishing a natural fracture activity prediction model based on the rock mechanics parameters for the entire formation, the three-dimensional stress field parameters for the entire formation and a three-dimensional natural fracture model to evaluate fracture activity; determining the well location based on a three-dimensional original site stress model, a three-dimensional fracturing prediction model and a fracture activity; and determining the well trajectory based on fracture activity, the three-dimensional fracturing prediction model, the three-dimensional original site stress model and the three-dimensional collapse pressure prediction model.

[0009] A second aspect of the present invention provides a method for increasing drilling speed, wherein drilling is performed using the well location and well trajectory determined by the well location and well trajectory determination method described above.

[0010] A third aspect of the present invention provides a method for transformation and production increase, which includes: drilling a well using the well location and well trajectory determined by the above-mentioned well location and well trajectory determination method; after drilling, obtaining a fracability profile based on a formation fracability model, dividing the wellbore longitudinal reservoir completion quality evaluation, and transforming the reservoir based on the evaluation results.

[0011] The fourth aspect of the invention provides a well location and well trajectory determination device, which includes: a rock mechanics parameter acquisition module, a three-dimensional stress field parameter acquisition module, a fracture activity evaluation module, a well location determination module and a well trajectory determination module; the rock mechanics parameter acquisition module is used to establish a three-dimensional rock mechanics parameter field model for the entire formation based on the formation pressure test and the flow phase constraints of each formation, and obtain the rock mechanics parameters of the entire formation; the three-dimensional stress field parameter acquisition module is used to establish a three-dimensional stress field prediction model for the entire formation based on the geological structure and the formation pressure field of each formation, and obtain the three-dimensional stress field parameters of the entire formation; the fracture activity evaluation module is used to establish a natural fracture activity prediction model based on the rock mechanics parameters of the entire formation, the three-dimensional stress field parameters of the entire formation and the three-dimensional natural fracture model, and evaluate the fracture activity; the well location determination module is used to determine the well location based on the three-dimensional original site stress model, the three-dimensional fracturing prediction model and the fracture activity; the well trajectory determination module is used to determine the well trajectory based on the fracture activity, the three-dimensional fracturing prediction model, the three-dimensional original site stress model and the three-dimensional collapse pressure prediction model.

[0012] A fifth aspect of the present invention provides an electronic device, which includes a processor and a memory, wherein the memory stores at least one computer program, and the at least one computer program is loaded and executed by one or more of the above-mentioned processors to enable the processor to execute the above-mentioned well location and well trajectory determination method.

[0013] A sixth aspect of the present invention provides a computer-readable storage medium storing at least one program code, which is loaded and executed by a processor to enable a computer to execute the above-mentioned method for determining well locations and well trajectories.

[0014] Through the above technical solution, the beneficial effects of the present invention are as follows:

[0015] (1) The method for determining well locations and well trajectories of the present invention combines geological structure modeling, well-seismic combined geophysical technology, and deep rock mechanics research to innovatively form a comprehensive evaluation system for oil and gas field geomechanical parameter fields. The comprehensive evaluation results can be applied to well trajectory design, achieving accurate selection of well locations and reasonable design of well trajectories, forming the prerequisite for increasing drilling speed and production.

[0016] (2) The drilling speed-up method of the present invention applies the comprehensive evaluation results of oil and gas field geomechanical parameters to the drilling speed-up method, fully considers the influence of the wellbore stability of different lithologies on the speed-up effect, and achieves the goal of increasing the drilling speed by optimizing the drilling parameters;

[0017] (3) The transformation and production increase method of the present invention applies the comprehensive evaluation results of oil and gas field geomechanical parameters to the completion and production increase, fully considering the influence of geostress, rock mechanics and fracture mechanics on the completion and production increase. By optimizing the completion and transformation parameters, a significant production increase is achieved, thereby achieving the ultimate goal of efficient development of complex oil and gas reservoirs.

[0018] (4) The present invention starts from the geological nature and the source of reservoir quality, determines the comprehensive evaluation results of the geomechanical parameters of the oil and gas field, and applies the comprehensive evaluation results of the geomechanical parameters of the oil and gas field to the specific production processes such as well site selection, well trajectory planning, drilling speed increase, and fracturing production increase in the oil and gas field drilling and completion engineering, forming an integrated solution. It can not only optimize the specific production processes in the oil field drilling and completion engineering and oil and gas reservoir engineering, but also take into account all factors. It can achieve a certain transformation and production increase effect in most complex oil and gas field blocks, and has the conditions for wide promotion;

[0019] (5) This invention will promote the deepening of geological understanding of ultra-deep oil and gas reservoirs, enrich ultra-deep petroleum geological theory, and directly improve the accuracy of ultra-deep reservoir quality evaluation and prediction;

[0020] (6) This invention will effectively promote the advancement of geological and engineering integration technology and solve some engineering geological problems related to safety, speed improvement and production improvement in ultra-deep drilling and completion projects;

[0021] (7) The present invention will significantly improve the efficiency of exploration and development of ultra-deep and complex oil and gas resources, while effectively reducing the safety, cost, and long-term risks and uncertainties faced in exploration and development.

[0022] Other features and advantages of the embodiments of the present invention will be described in detail in the subsequent detailed description. BRIEF DESCRIPTION OF THE DRAWINGS

[0023] The accompanying drawings are used to provide a further understanding of the embodiments of the present invention and constitute a part of the specification. Together with the following detailed description, they are used to explain the embodiments of the present invention, but do not constitute a limitation of the embodiments of the present invention. In the accompanying drawings:

[0024] FIG1 is a flow chart of a comprehensive evaluation method for oil and gas field geomechanical parameters according to an embodiment of the present invention;

[0025] FIG2 is a technical flow chart of full-layer three-dimensional in-situ stress field modeling provided by an embodiment of the present invention;

[0026] FIG3 is a technical flow chart of rock mechanics experiments on different lithologic formations provided by an embodiment of the present invention;

[0027] FIG4 is a technical flow chart of three-dimensional natural fractures and their activity prediction provided by an embodiment of the present invention;

[0028] FIG5 is a technical flow chart of well location and trajectory optimization provided by an embodiment of the present invention;

[0029] FIG6 is a technical flow chart of drilling speed optimization provided by an embodiment of the present invention;

[0030] FIG7 is a schematic diagram of a drilling speed-up optimization result provided by an embodiment of the present invention;

[0031] FIG8 is a schematic diagram of a well completion modification and production increase method according to an embodiment of the present invention;

[0032] FIG9 is a schematic diagram of a three-dimensional stress field model of the Keshen 10 structure provided by an embodiment of the present invention;

[0033] FIG10 is a schematic diagram of a wellbore stability analysis of a simulated vertical well and a highly deviated well provided by an embodiment of the present invention;

[0034] FIG11 is a schematic diagram of the natural fracture orientation of the wellbore of Keshen 10 Well according to an embodiment of the present invention;

[0035] FIG12 is a schematic diagram of the inclination angle of natural fractures in the wellbore of Keshen 10 Well according to an embodiment of the present invention;

[0036] FIG13 is a schematic diagram of crack opening rates under different injection pressures provided by an embodiment of the present invention. DETAILED DESCRIPTION

[0037] The following describes the specific implementation of the embodiment of the present invention in detail with reference to the accompanying drawings. It should be understood that the specific implementation described herein is only used to illustrate and explain the embodiment of the present invention and is not used to limit the embodiment of the present invention.

[0038] Example 1

[0039] Referring to FIG1 , a first embodiment of the present invention provides a method for determining a well location and well trajectory, the method comprising the following steps:

[0040] Step S101: Based on the formation pressure test and the flow phase constraints of each formation, a three-dimensional rock mechanics parameter field model of the entire formation is established to obtain the rock mechanics parameters of the entire formation.

[0041] Step S102: Based on the geological structure and the formation pressure field of each formation, a three-dimensional full-layer stress field prediction model is established to obtain the three-dimensional stress field parameters of the full-layer.

[0042] Step S103: establishing a natural fracture activity prediction model based on the rock mechanics parameters of the entire layer, the three-dimensional stress field parameters of the entire layer, and the three-dimensional natural fracture model to evaluate fracture activity.

[0043] Step S104: determining the well location based on the three-dimensional original site stress model, the three-dimensional fracturability prediction model, and the fracture activity.

[0044] Step S105: determining the well trajectory according to the fracture activity, the three-dimensional fracturability prediction model, the three-dimensional in situ stress model and the three-dimensional collapse pressure prediction model.

[0045] Here, the three-dimensional original site stress model refers to the three-dimensional current site stress model.

[0046] Furthermore, in a possible implementation, in step S101, a three-dimensional rock mechanics parameter field model of the entire formation is established based on the formation pressure test and the flow phase constraints of each formation. The process of obtaining the rock mechanics parameters of the entire formation may include but is not limited to the following sub-steps S1011 to S1014 (as shown in Figure 2).

[0047] Sub-step S1011: Based on the structural interpretation and geological stratification comparison data, a three-dimensional structural framework model of the entire layer from the ground to the target layer is established.

[0048] Here, it should be noted that the structural interpretation data should at least include the structural interpretation results from the ground to the target stratum and the structural interpretation results of the faults.

[0049] The three-dimensional structural framework model of the entire layer system should include the stratigraphic model and fault model of each layer to reflect the three-dimensional distribution characteristics of the stratigraphic layers and faults in the study area.

[0050] Sub-step S1012: Establish sedimentary facies / lithofacies models for each stratum in the target area based on the full-stratum 3D structural framework model, well logging data, and well logging interpretation results.

[0051] Sub-step S1013: Establishing a full-stratum rock physical parameter field model using the sedimentary facies model or lithofacies model as a constraint.

[0052] Here, it should be noted that the full-stratum rock physical parameter field model may include: sedimentary facies / lithologic facies parameter model, porosity parameter model, and density parameter model.

[0053] Sub-step S1014: Establish a three-dimensional rock mechanics parameter field model for the entire formation based on the rock physical parameter field model for the entire formation, formation pressure testing, and flow phase constraints for each formation from the ground.

[0054] Here, it should be noted that the full-layer rock mechanics parameter model can include: Young's modulus, Poisson's ratio and compressive strength.

[0055] Furthermore, in a possible implementation, before sub-step S1013, a sedimentary facies model or a lithofacies model may be selected based on rock mechanics experimental results and one-dimensional rock mechanics parameter interpretation results.

[0056] For example, different types of rock mechanics experiments are carried out on different lithologic geological bodies to obtain rock mechanics experimental results for different lithologic geological bodies.

[0057] Among them, different lithologic geological bodies include sandstone layers, mudstone, gypsum, salt rock, tight sandstone, fractured sandstone, coal and carbonate rock.

[0058] Different types of rock mechanics experiments include uniaxial rock mechanics experiments at different temperatures, triaxial rock mechanics experiments at different temperatures, uniaxial rock mechanics experiments under different fluids, triaxial rock mechanics experiments under different fluids, uniaxial rock mechanics experiments at different loading rates, and triaxial rock mechanics experiments at different loading rates.

[0059] Taking the Tarim Basin as an example, the strata there are fully developed, ranging from the Quaternary to the Nanhua System. To clarify the rock mechanical properties of different lithologic bodies and their impact on reservoirs and engineering, different types of rock mechanical experiments are necessary. As shown in Figure 3, typical rock types in the Tarim Basin include gravel beds, mudstones, gypsum salt, salt rock, tight sandstone, fractured sandstone, coal-bearing strata, and carbonate rocks. Because rocks are products of geological processes, their geological nature—namely, their physicality, structure, occurrence, and evolution—must be considered when analyzing their rock mechanical properties. This includes mineral composition, structural characteristics, confining pressure, temperature, and fluid conditions. Therefore, before conducting various rock mechanical experiments, XRD and thin-section analysis are required to clarify the mineral composition and structural characteristics. CT scanning and three-dimensional reconstruction techniques are then used to visually display the complete rock information. Uniaxial and triaxial rock mechanical experiments are then conducted under different temperatures, fluids, and loading rates, and repeated loading experiments are performed as needed. This allows for a systematic analysis of rock mechanical properties, providing fundamental data for studying rock failure mechanisms.

[0060] Furthermore, in a possible implementation, in step S102, a three-dimensional full-layer stress field prediction model is established based on the geological structure and the formation pressure field of each stratum. The process of obtaining the three-dimensional stress field parameters of the full-layer may include but is not limited to the following sub-steps S1021 to S1022 (as shown in Figure 2).

[0061] Sub-step S1021: Establishing the formation pressure field of each formation.

[0062] Sub-step S1022: setting boundary conditions according to the strength of the tectonic stress background in the target area, and establishing the three-dimensional stress field parameters of the entire layer system using the finite element numerical simulation method.

[0063] Here, it should be noted that the three-dimensional stress field parameters of the entire layer system include: vertical stress, horizontal maximum principal stress, horizontal minimum principal stress and principal stress direction.

[0064] Furthermore, in a possible implementation, a three-dimensional full-layer stress field prediction model is established based on the geological structure and the formation pressure field of each formation. The process of obtaining the three-dimensional stress field parameters of the full-layer system can also include step S1023: evaluating the formation pressure of each layer, and comparing the evaluation results with the three-dimensional stress field parameters of the full-layer system. If the accuracy requirements are not met, the boundary conditions are reset and the finite element numerical simulation calculation is performed again.

[0065] Furthermore, in a possible implementation, in step S103, a natural fracture activity prediction model is established based on the rock mechanical parameters of the entire formation, the three-dimensional stress field parameters of the entire formation, and the three-dimensional natural fracture model. The process of evaluating fracture activity may include but is not limited to the following sub-steps S1031 to S1032.

[0066] Sub-step S1031: collecting the three-dimensional stress field parameters of the entire layer system to each fracture of the three-dimensional natural fracture model.

[0067] Here, it should be noted that the three-dimensional stress field parameters of the entire layer system may include: vertical stress, horizontal maximum principal stress, horizontal minimum principal stress and principal stress direction.

[0068] Sub-step S1032: Calculate the effective normal stress σ of each crack Ne And shear stress τ, according to the shear stress τ and the effective normal stress σ Ne The ratio of is used to evaluate the crack activity.

[0069] Furthermore, in a possible embodiment, the effective normal stress σ Ne Obtained by the following formula: σ Ne =l 2 σ1+m 2 σ2+n 2 σ3 (Equation 1)

[0070] The shear stress τ is obtained by the following formula: τ 2 =l 2 m 2 (σ1-σ2) 2 +m 2 n 2 (σ2-σ3) 2 +n 2 l 2 (σ3-σ1) 2 (Formula 2)

[0071] Where, l = cos(θ), θ is the crack inclination; is the crack inclination; γ is the angle between the maximum horizontal principal stress and the north direction; σ1 is the stress with the largest stress value among the vertical stress, the maximum horizontal principal stress, and the minimum horizontal principal stress; σ2 is the stress with the middle value among the vertical stress, the maximum horizontal principal stress, and the minimum horizontal principal stress; σ3 is the minimum stress among the vertical stress, the maximum horizontal principal stress, and the minimum horizontal principal stress.

[0072] Furthermore, in a possible implementation, in sub-step S1031, the three-dimensional natural fracture prediction model can be obtained by the following method (as shown in FIG4 ):

[0073] Sub-step S10311: Establish a three-dimensional natural fracture DFN model of the target area based on the distribution trend of the fractures.

[0074] Sub-step S10312: Correcting the three-dimensional natural fracture DFN model using the single well fracture interpretation results to form the three-dimensional natural fracture prediction model.

[0075] Furthermore, in a possible embodiment, in sub-step S10311, the process of establishing a three-dimensional natural fracture DFN model of the target area according to the distribution trend of the fractures may include but is not limited to the following sub-steps S103111 to S103112 (as shown in FIG4 ).

[0076] Sub-step S103111: Based on the fracture interpretation results, geological and structural regional background laws, and core fracture description results, obtain the single well fracture type, classify fault-derived fractures and fractures related to fold deformation, and analyze the occurrence parameters of various fractures.

[0077] Sub-step S103112: predict the distribution trends of fault-related cracks and fold-related cracks respectively.

[0078] Furthermore, in a possible implementation, in sub-step S103112, the process of predicting the distribution trends of fault-related cracks and fold-related cracks can be implemented in the following manner (as shown in FIG4 ).

[0079] (a) For fault-related cracks: The distribution range of fault-derived cracks is obtained through three-dimensional fault throw recovery calculation, and the distribution trend of all fault-derived cracks in the study area is obtained by calculating the fault throw size.

[0080] (b) For fold-related cracks: Through fold recovery calculation, the magnitude of structural deformation is obtained in order to analyze the distribution of cracks caused by structural deformation; through the calculation of fold deformation, the distribution trend of cracks generated in all strata in the study area during the fold deformation process is obtained.

[0081] Furthermore, in a possible embodiment, in step S104, the process of determining the well location based on the three-dimensional original site stress model, the three-dimensional fracturability prediction model and the fracture activity can be achieved in the following manner (as shown in FIG5 ): based on the three-dimensional original site stress model, the three-dimensional fracturability prediction model and the natural fracture activity prediction model, the well location is preferably determined in an area of ​​the target layer with weak stress and an area of ​​the target layer with good fracture activity and high fracturability.

[0082] Furthermore, in a possible embodiment, in step S105, the process of determining the well trajectory based on the fracture activity, the three-dimensional fracability prediction model, the three-dimensional original site stress model and the three-dimensional collapse pressure prediction model can be achieved in the following manner (as shown in FIG5 ): based on the three-dimensional original site stress model, the three-dimensional fracability prediction model, the natural fracture activity prediction model and the three-dimensional collapse pressure prediction model, the well trajectory that encounters the most natural fractures, has high formation fracability and high formation collapse pressure is preferably drilled.

[0083] Furthermore, in a possible implementation manner, the three-dimensional in-situ stress model in step S104 is obtained by:

[0084] (1) Evaluate the rock mechanical parameters based on the well logging data, establish a one-dimensional geomechanical model, and evaluate the formation pore pressure;

[0085] (2) Perform joint well-seismic inversion to obtain the three-dimensional wave impedance attribute volume of the entire formation;

[0086] (3) Based on the relationship between P-wave and S-wave and density established by drilling, the wave impedance body is converted into P-wave, density, S-wave and formation mud content data;

[0087] (4) Predicting formation pressure based on P-wave, density, S-wave and formation mud content to obtain formation pressure prediction data;

[0088] (5) Based on the predicted data of formation pressure and the wellbore stability of different lithologic formations throughout the wellbore, a three-dimensional in-situ stress model including pressure distribution in three-dimensional space is formed.

[0089] It should be noted that the formation pressure referred to in the present invention includes formation pore pressure, formation collapse pressure, formation fracture pressure, lost circulation pressure, and closure pressure. Formation pore pressure can be predicted using the nonlinear trendline method for sandstone and mudstone and / or the multi-rock physics fitting method for carbonate rocks. Formation collapse pressure and formation fracture pressure can be predicted using the Mohr-Coulomb theory.

[0090] The three-dimensional in-situ stress model covers the pressure distribution in three-dimensional space and can be used to characterize the regional laws of wellbore stability.

[0091] In addition, the three-dimensional original site stress model can be corrected using the coring data and the measured data to obtain a corrected three-dimensional original site stress model.

[0092] Furthermore, in a possible implementation, the three-dimensional fracturability prediction model in step S104 can be obtained in the following manner:

[0093] (1) Based on the well logging data and the rock mechanical parameters of the target layer, a one-dimensional geomechanical model is established to obtain the current ground stress profile;

[0094] (2) Based on the natural fracture information of the wellbore and the current ground stress profile obtained from the imaging logging data, the pressure at which shear slip occurs in the natural fracture is obtained;

[0095] (3) Establish a formation fracturability model based on rock brittleness, toughness, ground stress, and shear slip pressure of natural fractures;

[0096] (4) Establish a three-dimensional fracturing prediction model based on the formation fracturing model.

[0097] The first embodiment of the present invention further provides a well location and trajectory determination device, which includes a rock mechanics parameter acquisition module, a three-dimensional stress field parameter acquisition module, a fracture activity evaluation module, a well location determination module, and a well trajectory determination module.

[0098] Among them, the rock mechanics parameter acquisition module is used to establish a three-dimensional rock mechanics parameter field model of the entire layer system based on the formation pressure test and the flow phase constraints of each layer, and obtain the rock mechanics parameters of the entire layer system.

[0099] The three-dimensional stress field parameter acquisition module is used to establish a three-dimensional full-layer stress field prediction model based on the geological structure and the formation pressure field of each layer, and obtain the three-dimensional stress field parameters of the full-layer system.

[0100] The fracture activity evaluation module is used to establish a natural fracture activity prediction model based on the rock mechanics parameters of the entire layer, the three-dimensional stress field parameters of the entire layer and the three-dimensional natural fracture model, and to evaluate the fracture activity.

[0101] The well location determination module is used to determine the well location based on the three-dimensional original site stress model, the three-dimensional fracturability prediction model and the fracture activity.

[0102] The well trajectory determination module is used to determine the well trajectory based on fracture activity, a three-dimensional fracturability prediction model, a three-dimensional in-situ stress model, and a three-dimensional collapse pressure prediction model.

[0103] It should be noted that the above-mentioned device only uses the division of the above-mentioned functional modules as an example to illustrate its functions. In actual applications, the above-mentioned functions can be assigned to different functional modules as needed, that is, the internal structure of the device can be divided into different functional modules to complete all or part of the functions described above. In addition, the device provided in the above embodiment and the method provided in the above embodiment are based on the same concept. The specific implementation process is detailed in the method embodiment and will not be repeated here.

[0104] The first embodiment of the present invention also provides an electronic device, which includes a processor and a memory, wherein the memory stores at least one computer program, and the at least one computer program is loaded and executed by one or more of the above-mentioned processors to enable the processor to implement the well location and well trajectory determination method in the above-mentioned embodiment.

[0105] Of course, the electronic device may also have components such as a wired or wireless network interface, a keyboard, and an input / output interface for input and output. The electronic device may also include other components for realizing various functions of the device, which will not be described in detail here.

[0106] The first embodiment of the present invention further provides a computer-readable storage medium, which stores at least one program code. The program code is loaded and executed by a processor to enable a computer to implement the well location and well trajectory determination method in the above embodiment.

[0107] Optionally, the computer-readable storage medium may be a read-only memory (ROM), a random access memory (RAM), a compact disc (CD-ROM), a magnetic tape, a floppy disk, or an optical disc data storage device. Those skilled in the art will appreciate that all or part of the steps in the above-mentioned embodiment method can be accomplished by instructing the relevant hardware through a program, and the program is stored in a storage medium, including several instructions for causing a single-chip microcomputer, a chip, or a processor to execute all or part of the steps of the method described in each embodiment of the present application. The aforementioned storage medium includes various media that can store program codes, such as a USB flash drive, a mobile hard disk, a read-only memory (ROM), a random access memory (RAM), a magnetic disk, or an optical disc.

[0108] Example 2

[0109] A second embodiment of the present invention provides a method for increasing drilling speed, wherein the method uses the well location and well trajectory determined by the well location and well trajectory determination method described in the first embodiment to perform drilling.

[0110] Specifically, when deploying well locations, the optimal well location can be selected based on the three-dimensional original site stress model, the natural fracture activity prediction model, and the three-dimensional fracturing ability prediction model, where the target layer has weak stress, good fracture activity, and high fracturing ability.

[0111] When drilling, it is possible to prioritize drilling into formations with high collapse pressure based on the three-dimensional collapse pressure prediction model and wellbore stability requirements.

[0112] When determining the well trajectory, the three-dimensional fracture activity model, the three-dimensional fracturing ability prediction model and the three-dimensional collapse pressure prediction model can be combined to select the well trajectory that encounters the most natural fractures, has high formation fracturing ability and high formation collapse pressure as the comprehensive optimal well trajectory.

[0113] By combining the optimal well location and the best well trajectory, the best well location and trajectory optimization can be formed that comprehensively considers the wellbore stability, drilling fractures and the benefits for later transformation.

[0114] In addition, during the drilling process, the formation pressure prediction data obtained by the well position and well trajectory determination method of the first embodiment can also be used to optimize the drilling fluid density window and drilling fluid performance indicators, and at the same time determine the wellbore structure design and the well control equipment pressure level design (as shown in Figure 6).

[0115] For example, Figure 7 shows a schematic diagram of the drilling speed optimization results. As shown in Figure 7, the well has four main pressure systems vertically: ① The surface-upper Jidike Formation is at normal pressure; ② The pore pressure coefficient of the middle and lower Jidike Formation gradually increases, reaching 1.6 in the Paleogene Suweiyi Formation; ③ The formation pressure coefficient of the Paleogene Kumugeliemu Group composite salt rock section reaches a maximum of 2.2; and ④ The pressure coefficient decreases to approximately 1.70 from the mudstone section at the base of the Paleogene Kumugeliemu Group to the Cretaceous. Based on the analysis of these four pressure systems, a five-layer casing structure was designed for this example well to ensure the safety, smoothness, and integrity of the well. Furthermore, considering the target formation pressure coefficient of 1.70, the well depth of 7,000 meters, the predicted absolute formation pressure of 119 MPa, and the fact that it is a gas well, the wellhead equipment, blowout preventer, and other well control equipment were designed to a pressure level of 140 MPa to ensure safe well control.

[0116] According to the above technical solution, the drilling speed increase of this embodiment will directly produce the following two benefits:

[0117] (1) The drilling speed-up method of this embodiment predicts the geomechanical parameters of ultra-deep oil and gas fields. By focusing on predicting the geomechanical parameters of oil and gas fields, such as the direction and size distribution of ground stress, the distribution of rock mechanics parameters, and the characteristics of natural fractures and fracture mechanics, and analyzing the impact of the above-mentioned geomechanical parameters on the quality of fractured reservoirs, the understanding of stress-controlled storage and production is proposed, and the distribution of reservoir quality is clarified. Based on this, the well point is selected and the well trajectory is optimized, which can lay the foundation for high well production from the geological source;

[0118] (2) The drilling speed-up method of this embodiment is based on the above-mentioned geomechanical parameter prediction results, conducts pore pressure prediction for the entire formation, clarifies the vertical distribution characteristics of pore pressure, and then analyzes the wellbore stability of formations such as conglomerate, mudstone, and composite salt rock, thereby optimizing the drilling fluid density, wellbore structure, and pressure level design of the well control equipment in the entire well section, providing guarantees for well control safety and drilling speed-up.

[0119] Example 3

[0120] A third embodiment of the present invention provides a method for increasing production, the method comprising the following steps:

[0121] Step S301: Drilling is performed using the well location and well trajectory determined by the well location and well trajectory determination method described above.

[0122] Step S302: After drilling is completed, a fracability profile is obtained according to the formation fracability model, the wellbore is divided into vertical reservoirs for completion quality evaluation, and the reservoir is transformed according to the evaluation results.

[0123] The wellbore vertical reservoir completion quality evaluation results obtained through the above steps can be used to optimize the reservoir stimulation method, oil testing layer section, perforation layer section, construction scale, construction pressure and pumping program.

[0124] Furthermore, in a possible embodiment, in step S302, the process of obtaining a fracability profile based on the formation fracability model and dividing the wellbore vertical reservoir completion quality evaluation may include but is not limited to the following sub-steps S3021 to S3023 (as shown in Figure 8).

[0125] Sub-step S3021: Establish a formation fracturability model based on rock brittleness, toughness, ground stress, and shear slip pressure of natural fractures.

[0126] Sub-step S3022: obtaining a fracturability profile according to the formation fracturability model;

[0127] Sub-step S3023: Based on the fracturability profile, the wellbore is divided into vertical reservoirs for completion quality evaluation.

[0128] Furthermore, in a possible implementation manner, the pressure at which shear slip occurs in the natural fracture in sub-step S3021 can be obtained in the following manner:

[0129] (1) Evaluate rock mechanical parameters based on well logging data, establish a one-dimensional geomechanical model, and obtain the current geostress profile;

[0130] (2) Based on the natural fracture information of the wellbore obtained from the imaging logging data and the current ground stress profile, the stress on the natural fracture of the wellbore is analyzed to obtain the pressure at which the natural fracture causes shear slip.

[0131] According to the above technical solution, the transformation and production increase of this embodiment will directly produce the following benefits:

[0132] The stimulation and production increase method of this embodiment is based on three-dimensional pressure prediction and geostress field modeling. It analyzes the stress characteristics of geologically predicted three-dimensional natural fractures. Then, a fracturing algorithm is established by comprehensively considering four factors: stress, cracks, brittleness, and fracture toughness. This algorithm forms a prediction of the vertical and horizontal distribution characteristics of fracturing. Combined with the vertical and horizontal mechanical characteristics of natural fractures, a completion quality evaluation system for ultra-deep fractured reservoirs is formed. Based on this, parameters such as the stimulation method, stimulation layer interval, perforation interval, stage classification scheme, and operation pressure during completion fracturing stimulation are optimized to support significant production increases.

[0133] Example 4

[0134] The fourth embodiment of the present invention takes the Keshen 10 structure as an example and applies the transformation and production increase method of the above embodiment to this area.

[0135] The Keshen 10 structure is controlled by the Keshen 6 and Kelasu faults. The Keshen 6 fault is the southern boundary fault, with the Keshen 10 and Keshen 6 structures hanging on its upper wall and the Keshen 2 structure on its lower wall. The Kelasu fault is the northern boundary fault of the Keshen 10 structure, with the Kela 8 structure hanging on its upper wall and the Kela 10 structure on its lower wall.

[0136] Figure 9 shows a three-dimensional geostress distribution profile obtained from a three-dimensional heterogeneous stress field study at Keshen 10. The current geostress state at Keshen 10 is as follows: the maximum horizontal principal stress is oriented NW in the west, nearly NW in the central anticline high, and gradually shifts to NE eastward. From north to south, the stress orientation changes from nearly NW to NE. The overall distribution pattern of the current minimum horizontal principal stress and horizontal stress difference is similar to that of the contour lines, forming a circular pattern. Values ​​are low at the anticline high and gradually increase toward the flanks. The current minimum horizontal principal stress values ​​of the Bashijiqike Formation in the Keshen 10 gas reservoir range from 110 to 160 MPa, and the horizontal stress difference is approximately 35 to 50 MPa.

[0137] Regarding well location and trajectory optimization, the low-stress zone in the Keshen 10 gas reservoir lies north of the projections of the Kela 1 and Kela 8 faults, within the overlapping region of the hanging wall structure. Considering geological factors and reservoir geomechanical characteristics, this low-stress zone represents a sweet spot for well placement. However, drilling vertical wells would encounter faults such as Kela 1 and Kela 8, as well as thicker salt formations, potentially presenting a series of complex engineering challenges and safety risks. Therefore, it is necessary to optimize well placement and highly deviated wellbore trajectories, taking into account current in-situ stress conditions.

[0138] Figure 10 shows the analysis results of the wellbore stability of simulated vertical and highly deviated wells. It can be seen that vertical wells have a very narrow safe mud window in the Kumugeliemu Group (salt layer) (low mud density easily leads to wellbore collapse, while high mud density causes mud loss). This poor wellbore stability is detrimental to safe and rapid drilling. However, a highly deviated well design with the wellhead tilted south and deviated to the north not only avoids shallow faults but also encounters a thinner salt layer. Furthermore, the mud window in the salt layer is wider (greater than 0.3 MPa / 100 m), resulting in better wellbore stability and a positive impact on safe, stable, and rapid drilling. Therefore, it can be concluded that the highly deviated well design for Well Keshen 1002 is superior to the vertical well design.

[0139] Practice has shown that the Keshen 1002 well has achieved high-yield oil and gas flow, proving that the optimization of high-angle wellbore trajectory considering the current ground stress state is correct, reasonable and effective.

[0140] Regarding stimulation and production optimization, imaging logging data revealed 87 fractures in the Bashijiqike Formation of Well Keshen 10, with an average fracture density of 0.3 fractures / m, and a fracture density of approximately 0.8 fractures / m in the Bashijiqike Formation. As shown in Figure 11, natural fractures are concentrated in a NWW direction, forming a small angle (averaging approximately 15°) with the maximum horizontal principal stress. As shown in Figure 12, natural fractures often have inclinations greater than 60°, primarily high-angle fractures. Based on the current in-situ stress evaluation results of the well, combined with the angle between the natural fracture direction and the maximum principal stress orientation (force-fracture angle), the openness of the natural fracture was simulated. The results show that: as shown in Figure 13 (a), when the net bottomhole pressure is 1.96 MPa / 100 m, one natural fracture is open, with an opening rate of 1.1%; as shown in Figure 13 (b), when the net bottomhole pressure is 2.05 MPa / 100 m, the opening rate is about 69%; and as shown in Figure 13 (c), when the net bottomhole pressure is 2.18 MPa / 100 m, almost all the natural fractures are open.

[0141] Generally speaking, 2.05 MPa / 100 m is the upper limit of pressure achievable in engineering. Therefore, it is believed that the natural fractures in Well Keshen 10 have a high openness (approximately 70%) during fracturing, which is conducive to oil and gas communication and migration. Small-scale acidizing and fracturing can be used to unblock and unclog the natural fractures. If the force-fracture angle is large (45°-60°) and the natural fracture openness is low (less than 50%), fracture network acidizing and fracturing should be considered to activate the natural fractures and artificially create a complex fracture network. If the natural fractures are not well developed and the force-fracture angle is large or nearly vertical, sand fracturing should be used to artificially create the main fractures. Therefore, perforating is preferred in strata with well-developed natural fractures (fracture density greater than 0.3 fractures / m), relatively low horizontal stress (2-3 MPa below the average), small force-fracture angle (<45°), and low fracture opening pressure (<2.05 MPa / 100 m). Nowadays, geostress analysis is an important evaluation step before reservoir transformation, which helps to increase oil and gas production and efficiency.

[0142] During the drilling process of the Keshen 1002 well, crews further optimized eight measures, including wellbore trajectory, drilling parameters, and wellbore cleaning. To address the development of thick salt deposits in the Keshen 10X well, the vertical section of the well employed oil-based drilling fluid coupled with Power-V and PDC drilling speed-up technology, resulting in a practical and effective drilling cycle 21 days faster than planned. Rotary steerable drilling speed-up tools were selected for the deflection section, achieving both deflection and speed-up, achieving a timeline 18 days faster than planned. The post-completion renovation significantly increased gas production, reaching 740,000 cubic meters per day. The open-flow rate increased from 300,000 cubic meters in the adjacent vertical well to 2.5 million cubic meters, an eight-fold increase.

[0143] In summary, the transformation and production increase method of the present invention establishes a high-precision comprehensive evaluation system for the geomechanical parameter field of oil and gas fields, and uses the comprehensive evaluation results of the geomechanical parameters of oil and gas fields to optimize well locations and well trajectories, ensuring the prerequisite for increasing drilling speed and production; and during drilling, the drilling parameters are optimized using the comprehensive evaluation results of the geomechanical parameters of oil and gas fields to achieve the goal of increasing drilling speed; after completion, the completion transformation parameters are optimized using the comprehensive evaluation results of the geomechanical parameters of oil and gas fields to achieve a significant increase in transformation production, thereby achieving the ultimate goal of efficient development of complex oil and gas reservoirs.

[0144] In the process of implementing the above-mentioned transformation and production increase methods, the following specific problems can be solved: ① Combining geological structure modeling, well-seismic combined geophysical technology with deep rock mechanics research to innovatively form a comprehensive evaluation technology for the geomechanical parameter field of oil and gas fields; ② Solving the technical problem that the existing medium-shallow rock mechanics theory and constitutive relationship are not suitable for ultra-deep layers, and the evaluation accuracy of ultra-deep rock mechanics parameters is low; ③ Solving the problem of quantitatively predicting the influence of geostress field, rock strength and pore pressure on the development of natural fractures and permeability around fractures in reservoir quality evaluation; ④ Solving the technical problem of predicting the mechanical activity of natural fractures and fractures under strong stress background; ④ Solving the technical problem of predicting the stability of drilling wellbore under the conditions of special lithology and fracture (crack) development; ⑤ Solving the technical problem of geomechanical evaluation of ultra-deep oil and gas reservoir transformation.

[0145] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention and not to limit it. Although the present invention has been described in detail with reference to the above embodiments, ordinary technicians in the field should understand that the specific implementation methods of the present invention can still be modified or replaced by equivalents. Any modification or equivalent replacement that does not depart from the spirit and scope of the present invention should be covered by the scope of protection of the claims of the present invention.

Claims

1. A method for determining a well location and a well trajectory, characterized in that: The method comprises: According to the formation pressure test and the flow phase constraints of each formation, a three-dimensional rock mechanics parameter field model of the entire formation is established to obtain the rock mechanics parameters of the entire formation; According to the geological structure and the formation pressure field of each layer, a three-dimensional stress field prediction model for the entire layer system is established to obtain the three-dimensional stress field parameters of the entire layer system; A natural fracture activity prediction model is established based on the rock mechanics parameters of the entire layer, the three-dimensional stress field parameters of the entire layer, and the three-dimensional natural fracture model to evaluate fracture activity. Determine the well location based on the 3D original site stress model, 3D fracturability prediction model and fracture activity; The well trajectory is determined based on fracture activity, a three-dimensional fracturability prediction model, a three-dimensional in situ stress model, and a three-dimensional collapse pressure prediction model.

2. The method for determining well location and well trajectory according to claim 1, characterized in that: According to the formation pressure test and the flow phase constraints of each formation, a three-dimensional rock mechanics parameter field model of the entire formation is established to obtain the rock mechanics parameters of the entire formation, including: Based on the structural interpretation and geological stratification comparison data, a three-dimensional structural framework model of the entire layer from the ground to the target layer is established; Based on the 3D structural framework model of the entire stratum, logging data and logging interpretation results, the sedimentary facies / lithological facies model of each stratum in the target area is established; Using sedimentary facies model or lithofacies model as constraints, establish a rock physical parameter field model for the entire stratum system; A three-dimensional rock mechanics parameter field model of the entire formation is established based on the rock physical parameter field model of the entire formation, formation pressure testing and flow phase constraints of each formation from the ground.

3. The method for determining well location and well trajectory according to claim 2, characterized in that: The full-stratum rock physical parameter field model includes: sedimentary phase / lithological phase parameter model, porosity parameter model and density parameter model; The full-layer rock mechanics parameter model includes: Young's modulus, Poisson's ratio and compressive strength.

4. The method for determining well location and trajectory according to claim 2, characterized in that: The method of establishing a three-dimensional rock mechanics parameter field model of the entire formation system according to the formation pressure test and the flow phase constraints of each formation to obtain the rock mechanics parameters of the entire formation system also includes: Before establishing the full-stratum rock physical parameter field model with the sedimentary facies or lithofacies model as a constraint, the sedimentary facies model or lithofacies model is selected based on the rock mechanics experimental results and the one-dimensional rock mechanics parameter interpretation results.

5. The method for determining well location and well trajectory according to claim 1, characterized in that: The method of establishing a three-dimensional full-layer stress field prediction model based on the geological structure and the formation pressure field of each layer to obtain the three-dimensional stress field parameters of the full-layer system includes: Establish the formation pressure field of each formation; Boundary conditions are set according to the strength of the tectonic stress background in the target area, and the finite element numerical simulation method is used to establish the three-dimensional stress field parameters of the entire layer system.

6. The method for determining well location and well trajectory according to claim 5, characterized in that: The method of establishing a three-dimensional full-layer stress field prediction model according to the geological structure and the formation pressure field of each layer to obtain the three-dimensional stress field parameters of the full-layer system also includes: The formation pressure of each layer is evaluated, and the evaluation results are compared with the three-dimensional stress field parameters of the entire layer system. If the accuracy requirements are not met, the boundary conditions are reset and the finite element numerical simulation calculation is performed again.

7. The method for determining well location and well trajectory according to claim 1, characterized in that: The three-dimensional stress field parameters of the whole layer system include: vertical stress, maximum horizontal principal stress, minimum horizontal principal stress, and principal stress direction; The method of establishing a natural fracture activity prediction model based on the rock mechanics parameters of the entire layer system, the three-dimensional stress field parameters of the entire layer system and the three-dimensional natural fracture model to evaluate fracture activity includes: Collecting the three-dimensional stress field parameters of each of the full-layer systems to each crack of the three-dimensional natural fracture model; Calculate the effective normal stress σ of each crack Ne and shear stress τ, according to the shear stress τ and the effective normal stress σ Ne The ratio of is used to evaluate the fracture activity.

8. The method for determining well location and trajectory according to claim 7, characterized in that: The effective normal stress σ Ne Obtained by the following formula: Ne = l 2 σ1+m 2 σ2+n 2 σ3 (Equation 1) The shear stress τ is obtained by the following formula: t 2 =l 2 m 2 (σ1-σ2) 2 +m 2 n 2 (σ2-σ3) 2 +n 2 l 2 (σ3-σ1) 2 (formula 2) Where l = cos(θ), θ is the crack inclination; is the crack inclination; γ is the angle between the maximum horizontal principal stress and the north direction; σ1 is the stress with the largest stress value among the vertical stress, the maximum horizontal principal stress and the minimum horizontal principal stress; σ2 is the stress with the middle value among the vertical stress, the maximum horizontal principal stress and the minimum horizontal principal stress; σ3 is the smallest stress among the vertical stress, the maximum horizontal principal stress and the minimum horizontal principal stress.

9. The method for determining well location and well trajectory according to claim 1 or 7, characterized in that: The three-dimensional natural fracture prediction model is obtained by the following method: According to the distribution trend of fractures, a three-dimensional natural fracture DFN model of the target area is established; The three-dimensional natural fracture DFN model is corrected by the single well fracture interpretation results to form the three-dimensional natural fracture prediction model.

10. The method for determining well location and well trajectory according to claim 9, characterized in that: The three-dimensional natural fracture DFN model of the target area is established according to the distribution trend of the fractures, including: According to the fracture interpretation results, geological and structural regional background laws and core fracture description results, the fracture types of single wells are obtained, fault-derived fractures and fractures related to fold deformation are divided, and the occurrence parameters of various fractures are analyzed; The distribution trends of fault-related cracks and fold-related cracks are predicted respectively.

11. The method for determining well location and well trajectory according to claim 10, characterized in that: The prediction of the distribution trends of fault-related cracks and fold-related cracks respectively includes: For fault-related cracks: obtain the distribution range of fault-derived cracks through three-dimensional fault recovery calculation, and obtain the distribution trend of all fault-derived cracks in the study area through calculation of fault distance size; For fold-related cracks: through fold recovery calculation, the magnitude of structural deformation is obtained in order to analyze the distribution of cracks caused by structural deformation; through the calculation of fold deformation, the distribution trend of cracks generated in all strata in the study area during the fold deformation process is obtained.

12. The method for determining well location and well trajectory according to claim 1, characterized in that: The method of determining the well location according to the three-dimensional original site stress model, the three-dimensional fracturability prediction model and the fracture activity includes: According to the three-dimensional original site stress model, the three-dimensional fracturability prediction model and the natural fracture activity prediction model, the well location is preferably determined in the target layer with weak stress and the area with good fracture activity and high fracturability of the target layer.

13. The method for determining well location and well trajectory according to claim 1, characterized in that: The method of determining the well trajectory according to the fracture activity, the three-dimensional fracturability prediction model, the three-dimensional original site stress model and the three-dimensional collapse pressure prediction model includes: According to the three-dimensional original site stress model, the three-dimensional fracturability prediction model, the natural fracture activity prediction model and the three-dimensional collapse pressure prediction model, the well trajectory with the most natural fractures, high formation fracturability and high formation collapse pressure is preferably drilled.

14. The method for determining well location and well trajectory according to claim 12 or 13, characterized in that: The three-dimensional original site stress model is obtained by the following method: Evaluate the rock mechanical parameters according to the logging data, establish a one-dimensional geomechanical model, and evaluate the formation pore pressure; Perform well-seismic joint inversion to obtain the three-dimensional wave impedance attribute volume of the entire formation; According to the relationship between P-wave and S-wave and density established by drilling, the wave impedance body is converted into P-wave, density, S-wave and formation mud content data; Predict formation pressure based on P-wave, density, S-wave and formation mud content to obtain formation pressure prediction data; The three-dimensional original site stress model including the pressure distribution in three-dimensional space is formed according to the predicted data of the formation pressure and the wellbore stability of the different lithology formations in the whole wellbore.

15. The method for determining well location and well trajectory according to claim 14, characterized in that: The formation pressure includes formation pore pressure, formation collapse pressure, formation fracture pressure, leakage pressure and closure pressure; Predicting the formation pore pressure by using a nonlinear trend line method for sandstone and mudstone and / or a multi-rock physical fitting method for carbonate rocks; The Mohr-Coulomb theory is used to predict the formation collapse pressure and the formation fracture pressure.

16. The method for determining well location and trajectory according to claim 14, characterized in that: The three-dimensional original site stress model is corrected using the coring data and the measured data to obtain a corrected three-dimensional original site stress model.

17. The method for determining well location and well trajectory according to claim 12 or 13, characterized in that: The three-dimensional fracturability prediction model is obtained by: According to the logging data and the rock mechanical parameters of the target layer, a one-dimensional geomechanical model is established to obtain the current geostress profile; Based on the natural fracture information of the wellbore and the current ground stress profile obtained from the imaging logging data, the pressure at which shear slip occurs in the natural fracture is obtained; Establish a formation fracturability model based on rock brittleness, toughness, ground stress and shear slip pressure of natural fractures; A three-dimensional fracturing prediction model is established based on the formation fracturing model.

18. A method for increasing drilling speed, characterized in that: Drilling is performed using the well location and well trajectory determined by the well location and well trajectory determination method according to any one of claims 1 to 17.

19. A method for increasing production, characterized in that: The method comprises: Drilling by using the well location and well trajectory determined by the well location and well trajectory determination method according to any one of claims 1 to 17; After drilling is completed, the fracturability profile is obtained according to the formation fracturability model, the wellbore vertical reservoir is divided for completion quality evaluation, and the reservoir is transformed according to the evaluation results.

20. The method for increasing production according to claim 19, characterized in that: The method of obtaining a fracturability profile according to the formation fracturability model and dividing the wellbore vertical reservoir completion quality evaluation includes: Establish a formation fracturability model based on rock brittleness, toughness, ground stress and shear slip pressure of natural fractures; Obtaining a fracturability profile according to a formation fracturability model; According to the fracturability profile, the wellbore vertical reservoir is divided for completion quality evaluation.

21. The method for increasing production according to claim 20, characterized in that: The pressure at which the natural fracture undergoes shear slip is obtained by: The rock mechanical parameters were evaluated based on the logging data, a one-dimensional geomechanical model was established, and the current geostress profile was obtained; Based on the natural fracture information of the wellbore obtained from the imaging logging data and the current ground stress profile, the stress on the natural fractures of the wellbore is analyzed to obtain the pressure at which the natural fractures undergo shear slip.

22. A device for determining a well location and trajectory, characterized in that: The device comprises: a rock mechanics parameter acquisition module, a three-dimensional stress field parameter acquisition module, a fracture activity evaluation module, a well location determination module and a well trajectory determination module; The rock mechanics parameter acquisition module is used to establish a three-dimensional rock mechanics parameter field model for the entire formation system and obtain the rock mechanics parameters of the entire formation system based on the formation pressure test and the flow phase constraints of each formation; The three-dimensional stress field parameter acquisition module is used to establish a three-dimensional full-layer stress field prediction model based on the geological structure and the formation pressure field of each layer, and obtain the three-dimensional stress field parameters of the full-layer system; Fracture activity evaluation module, used to establish a natural fracture activity prediction model based on the rock mechanics parameters of the entire layer system, the three-dimensional stress field parameters of the entire layer system and the three-dimensional natural fracture model, and evaluate fracture activity; A well location determination module, used to determine the well location based on a three-dimensional original site stress model, a three-dimensional fracturability prediction model and fracture activity; The well trajectory determination module is used to determine the well trajectory based on the fracture activity, the three-dimensional fracturability prediction model, the three-dimensional original site stress model and the three-dimensional collapse pressure prediction model.

23. An electronic device, characterized in that: The electronic device includes a processor and a memory, wherein the memory stores at least one computer program, and the at least one computer program is loaded and executed by one or more of the above processors so that the processor executes the method for determining the well location and well trajectory according to any one of claims 1 to 17.

24. A computer-readable storage medium, characterized in that: The computer-readable storage medium stores at least one program code, and the program code is loaded and executed by a processor to enable a computer to execute the method for determining the well location and well trajectory according to any one of claims 1 to 17.

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